Flex›Source - E.ON Nätutvecklingsplan 2025-2034

Source - E.ON Nätutvecklingsplan 2025-2034

E.ON Energidistribution AB — Nätutvecklingsplan 2025–2034 (Network Development Plan 2025–2034). Published December 2024. E.ON’s first-ever DNDP, produced in compliance with Ei regulation EIFS 2024:1. 89 pages. Contact: natutvecklingsplaner@eon.se.

Metadata

FieldValue
PublisherE.ON Energidistribution AB
DateDecember 2024
TypeMandatory DNDP (nätutvecklingsplan)
Legal basisDirective 2019/944 Art. 32(3); Ei EIFS 2024:1
Consultation15 Sep – 1 Dec 2024; ~90 respondents; 10 regional dialogue meetings with 15 counties and ~105 municipalities
Coverage15 Swedish counties; ~143,000 km of grid; ~1.1 million customers (~1/5 of all Swedish grid customers; ~1/4 of all Swedish grid km)

Summary

E.ON is Sweden’s largest DSO by grid length and one of the three largest by customer count. This is the company’s first DNDP, produced under Ei’s template (EIFS 2024:1). It covers both local (lokalnät, <30 kV) and regional (regionnät, 30–130 kV) grids, organized by Swedish county.

The document is structured around Ei’s mandatory DNDP template: (1) company and grid information; (2) capacity need forecast; (3) planned investments and alternative solutions; (4) overall assessment; (5) consultation report.

Key claims

Grid overview

  • ~143,000 km of grid (air lines + underground cable) — approximately 1/4 of all Swedish grid
  • ~1.1 million connected customers — approximately 1/5 of all Swedish grid customers
  • ~50 connected third-party distribution companies
  • Grid spans: Skåne, Blekinge, Kronoberg, Kalmar, Halland, Jönköpings, parts of Östergötland, Västra Götaland, Örebro, Stockholm, Uppsala, Gävleborg, Västernorrland, Jämtland, Västerbotten counties
  • Regional (regionnät) grid: ~500 regional lines, ~600 fördelningsstationer (distribution substations), 40–130 kV
  • Local (lokalnät) grid: ~48,000 nätstationer (transformer stations), 6–20 kV (MS) and 0.4 kV (LV)
  • Interconnections to Denmark (Energinet) from E.ON’s Skåne regional grid

Demand forecast (2025–2034)

  • Average 13% increase in peak load by 2029, 17% by 2034 (vs. historical baseline through 2023/24)
  • EVs in E.ON’s local grid: ~100,000 (baseline) → ~700,000 by 2034
  • Small-scale solar in E.ON’s local grid: ~1 GW → ~2.6 GW by 2034; additional ~1.7 GW in grids fed by E.ON’s regional grid
  • ~30 GW of solar applications in queue as of 2024 — if fully realized, would approximate Sweden’s total annual electricity consumption; not included in the investment planning forecast
  • Key demand drivers: EV charging (home + public), organic growth, large new connections, distributed solar production
  • Swanneck dynamic developing in multiple counties: summer daytime overproduction shifting areas from net consumption to net production

County-level peak load figures (MW) — highlights:

CountyBaseline high2034 highChange
Skåne2,8433,089+9%
Västernorrland1,1341,196+5%
Halland660724+10%
Jönköping594664+12%
Kalmar622685+10%
Stockholm556655+18%
Kronoberg467524+12%
Blekinge381477+25%
Östergötland329362+10%
Örebro294347+18%

Capacity situation (A/B/C ratings per municipality and time horizon)

E.ON uses a three-level capacity assessment:

  • A: can meet forecast with low risk of capacity constraints; good conditions for additional connections
  • B: can meet forecast; additional connections beyond forecast increase risk of constraints; moderate risk for large connections
  • C: additional measures needed to meet forecast; high risk for large connections

Assessment covers 0–2 years, 3–5 years, and 6–10 years for both production and consumption separately.

Most constrained areas (production side):

  • Jönköping: C for production in most municipalities across all time horizons
  • Kalmar: C for production (Borgholm, Hultsfred, Kalmar city, Mörbylånga, Torsås across all horizons)
  • Kronoberg: C in Markaryd, Älmhult
  • Skåne: C in Hässleholm (long-term), Kristianstad, Östra Göinge

Most constrained areas (consumption side):

  • Stockholm/Uppsala: Uppsala — Enköping and Håbo both C for 0–5 years (dependency on Vattenfall overlying grid reinforcements, planned late 2029); Stockholms-Bro, Vaxholm, Österåker
  • Jönköping: Gislaved C all horizons; Vaggeryd C 0–5 years
  • Skåne: Svalöv C all horizons; Hässleholm, Klippan, Åstorp, Ängelholm, Örkelljunga C medium/long-term

Impact of NordSyd: E.ON explicitly notes that Svk’s NordSyd construction 2027–2030 will temporarily increase loads on E.ON’s Gävleborg and Västernorrland regional grids during the construction period. Full relief expected when NordSyd complete 2032–2035.

Dependency on overlying grid: Stockholm requires Vattenfall Eldistribution to reinforce their overlying regional grid (planned late 2029) before E.ON’s own planned capacity can be fully utilized.

Planned investments

  • 30 BSEK invested in last 10 years
  • Min. 23 BSEK more by 2027 — largest investment program in company history
  • 246 major regional grid projects listed (stations + lines, reinvestment + new investment)
  • Additional thousands of local grid projects not individually listed
  • System studies (systemutredningar) ongoing/planned for Jönköping, Kalmar, Kronoberg, Skåne — these will identify further investments not yet in this DNDP
  • New station lead time: 3–5 years; new line lead time: 5–10 years

Flexibility needs

Total stated flexibility need: ~700 MW flexible power and ~1 TWh flexible energy per year in coming years. These figures are weather-conditional (cold-winter peak).

County-level flexibility needs (all figures upper-bound, weather-conditional):

CountyPower 0–2 yr (MW)Power 3–5 yr (MW)Power 6–10 yr (MW)Energy 0–2 yr (MWh)Energy 3–5 yr (MWh)Energy 6–10 yr (MWh)
Skåne47–24030–28030–2900–66,0000–85,0000–80,000
Jönköping0–950–1000–1200–220,0000–240,0000–260,000
Kronoberg0–850–850–1000–210,0000–220,0000–250,000
Kalmar0–700–900–1000–160,0000–170,0000–180,000
Östergötland0–650–600–650–180,0000–150,0000–170,000
Halland0–250–250–350–26,0000–30,0000–34,000
Blekinge0–250–300–300–17,0000–22,0000–24,000
Örebro2–162–210–210–23,0000–25,0000–29,000
Uppsala5–195–360–150–2,2000–6,8000–4,900
Stockholm5–140–280–100–1,2000–11,0000–100
Västra Götaland0–50–50–50–7,0000–8,0000–8,000
Gävleborg000000
Jämtland000000
Västerbotten000000
Västernorrland000000

Important caveat: pending uninvestigated connection applications (not yet included in forecasts) would — if realized — increase stated needs substantially: Skåne +90–130%, Stockholm +100–280%, Uppsala +50–500%, Kalmar +40–80%.

Methodology: flexibility needs assessed at fördelningsstationer (substations at regionnät/lokalnät interface). N-1 criterion used. Dimensioning fault: one of two parallel transformers at a substation fails. Flexibility need = gap between forecast and N-1 capacity, including planned investments. Production-side (summer) flexibility assessment not yet developed — stated ambition to address this in future plans.

Current flexibility tools

E.ON describes a “verktygslåda” (toolbox) of four tools:

1. Flexibility markets (SWITCH)

  • 5 markets operated in season 2023/24 (Hässleholm, Bålsta, Vaxholm, Södra Skåne — all local; + Järfälla test market)
  • Expanded to 9 markets in 2024/25: + Enköping, Kallhäll, Kungsängen, Norra Örebro, Nordöstra Skåne
  • Products: Säsongstillgänglighet, Tillgänglighetsordrar (DayAhead), Direktordrar (IntraDay) — with availability + activation compensation
  • Minimum 0.1 MW; uthållighetskrav 1 hour across all products
  • Resources in 2023/24: heat pumps (individual + aggregated), backup generators, batteries, commercial EV charger clusters
  • E.ON licenses SWITCH platform to other actors needing a flexibility market tool

2. Villkorade avtal

  • Ei approved E.ON’s methodology 19 March 2024 — E.ON exited pilot phase and entered fully operational status
  • Pilots running since 2020
  • Offered in all E.ON network areas under unified method and criteria
  • E.ON principles: no distinction between new and existing customers; valid network-wide; time-limited (until capacity constraint resolved); customer must be offered prima capacity when constraint resolved; LIFO curtailment order (most recent = first); right to penalize/disconnect non-compliant customers
  • Market-first: villkorade avtal used only after market alternatives exhausted

3. Tariffs

  • New efficiency tariffs per Ei EIFS 2022:1 to be in place by 1 January 2027
  • Expected to provide implicit flexibility through price signals

4. Technical alternatives

  • Omkopplingar (grid reconfiguration): proactive or reactive changes to normal switching state
  • Dynamic Line Rating (DLR): dynamic calculation of actual line capacity based on temperature and wind. Currently used on 1 line; ambition to deploy on all 130 kV lines during 2025

E.ON is also developing an investment valuation model that incorporates: existing asset economic life; incremental depreciation from new investment; flexibility alternative cost; social economic value of faster customer connection; and embodied carbon avoided from not building.

Relevance to existing wiki topics

  • Distribution Network Development Plan: fills the major data gap — this is the first actual Swedish DNDP ingested; provides county/municipality A/B/C capacity map; confirms 10-year horizon; shows how Ei’s template is implemented in practice
  • E.ON Energidistribution: fills grid coverage data gap (1/4 of Swedish grid, 1/5 of customers); fills SWITCH commercial model gap (licensed to others); confirms DLR deployment; confirms March 2024 villkorade avtal operational transition
  • Flexibility Need Assessment: most granular public data from a major Swedish DSO for FNA context; county-level quantification; total 700 MW / 1 TWh headline figure from E.ON alone
  • Flexibility Market: confirms 9 markets in 2024/25; resources participating in 2023/24 season; production-side flexibility gap noted; DLR as complementary technical tool
  • SWITCH: confirms SWITCH licensed to other DSOs (resolves data gap); confirms product table from user documentation
  • Villkorade Avtal: precise date Ei approved E.ON’s methodology (19 March 2024); confirms national rollout across all E.ON areas; confirms LIFO and other operational principles
  • NordSyd: adds DSO perspective — NordSyd construction 2027–2030 temporarily increases loads on E.ON’s Gävleborg and Västernorrland regional grids; full relief 2032–2035
  • Dynamic Line Rating: introduces new concept not previously in wiki

New concepts introduced

  • Dynamic Line Rating (DLR) — dynamic capacity calculation for overhead lines based on real-time weather; E.ON deploying on all 130 kV lines in 2025